In a reservoir characterization study of the Hontomín deep saline aquifer, the impact of geological heterogeneities on reservoir storage capacity and the migration of the CO₂ plume is explored. This work presents, for the first time, very long-term (up to 200 years) simulations of CO₂ injection into the naturally fractured Sopeña Formation, of the lower Jurassic age, at Hontomín. CO₂ injection was simulated as a dual permeability case with Eclipse compositional software. The matrix permeability of the carbonate reservoir is quite low (0.5 mD) and thus fluid flow through the fractures dominates. The reservoir is dissected by eight normal faults which limited its south-east extension and divided it into several segments. The effect of geological heterogeneities was tested through scenario-based modeling and variation of parameters characterizing heterogeneity within realistic limits based on other similar formations. This modeling approach worked well in Hontomín where the database is completely scarce. The plume migration, the reservoir storage capacity, and pressure, were each influenced in diverse ways by incorporating particular types of heterogeneities. The effect of matrix heterogeneities on reservoir storage capacity was substantial (by factors up to ∼2.8×), compared to the plume migration. As the reservoir matrix permeability heterogeneity increased, the reservoir storage capacity markedly decreased, whilst an increase in porosity heterogeneity significantly increased it. The vertical gas migration in the homogeneous base case was relatively larger compared to the heterogeneous cases, and gas accumulated underneath the caprock via hydrodynamic trapping. It was also observed that, in heterogeneous cases, gas saturation in rock layers from top to bottom was relatively high compared to the base case, for which most of the gas was stored in the topmost layer. In contrast, the impact on storage capacity and plume movement of matrix vertical to horizontal permeability ratio in the fractured carbonate reservoir was small. The impact of the transmissibility of faults on reservoir pressure was only observed when the CO₂ plume reached their vicinity.

在Hontomín深层盐水层的储层表征研究中，探讨了地质异质性对储层储存能力和CO ₂羽流迁移的影响。这项工作首次提出了长期（长达200年）对本田下侏罗纪较低侏罗纪天然裂缝Sopeña地层中CO ₂注入的模拟。一氧化碳₂使用Eclipse合成软件将注射液模拟为双重渗透情况。碳酸盐岩储层的基质渗透率非常低（0.5 mD），因此流过裂缝的流体占主导地位。该水库由八个正常断层解剖，这些断层限制了它的东南向延伸并将其划分为几个部分。地质异质性的影响是通过基于场景的建模和表征异质性的参数变化（基于其他类似地层，在现实范围内）进行测试的。这种建模方法在Hontomín的数据库非常匮乏的情况下效果很好。通过并入特定类型的非均质性，以不同的方式分别影响羽流运移，储层的存储能力和压力。与羽流运移相比，基质非均质性对储层储藏能力的影响是巨大的（高达2.8倍）。随着储层基质渗透率非均质性的增加，储层的储存能力显着降低，而孔隙度非均质性的增加则显着提高了储层的非均质性。与非均质情况相比，均质基础情况下的垂直气体运移相对较大，并且气体通过流体动力捕集而在盖层下方聚集。还观察到，在非均质情况下，与基本情况相比，从上到下的岩石层中的气体饱和度相对较高，对于基本情况而言，大多数气体都存储在最上层中。相比之下，裂缝性碳酸盐岩储层对基质储量和垂向羽状渗透率的影响较小。断层可传递性对储层压力的影响只有在CO发生时才能观察到。₂股羽毛到达了附近。